Method and system for simultaneous seismic data acquisition of multiple source lines

ABSTRACT

Systems and methods for reducing survey time while enhancing acquired seismic data quality are provided. Data corresponding to plural source lines are acquired simultaneously, using sources at cross-line distance at least equal to their illumination width, with at least one source being towed above a streamer spread.

CROSS REFERENCE TO RELATED APPLICATIONS

The present application is a continuation of U.S. patent applicationSer. No. 15/210,111, filed Jul. 14, 2016, and claims the benefit ofpriority under 35 U.S.C. § 119(e) to U.S. Provisional Application No.62/193,667, filed on Jul. 17, 2015, and U.S. Provisional Application No.62/197,580, filed on Jul. 28, 2015, the entire contents of which arehereby incorporated by reference into the present application.

TECHNICAL FIELD

Embodiments of the subject matter disclosed herein generally relate tomethods and systems for seismic data acquisition of multiple sourcelines and, more particularly, to mechanisms and techniques for acquiringseismic data related to two or more sources along a sail line, with asingle streamer spread.

BACKGROUND

In oil and gas exploration and exploitation, marine seismic surveys arean important tool for making drilling-related decisions. Seismic dataacquired during such a survey is processed to generate a profile, whichis a three-dimensional approximation of the geophysical structure underthe seafloor. This profile enables those trained in the field toevaluate the presence or absence of oil and/or gas reservoirs, whichleads to better management of reservoir exploitation. Enhancing seismicdata acquisition and processing is an ongoing process.

FIG. 1 is a vertical-plane view of a generic marine survey setup 100. Avessel 101 tows a seismic source 102 (note that, for simplicity, thesource's full configuration is not shown) and streamers (only onestreamer 104 is visible in this view) in a towing direction T. When theseismic source is activated, seismic energy is emitted into the waterand propagates into the rock formation under the seafloor 110. Theseismic energy is partially reflected and partially transmitted atinterfaces where the acoustic impedance changes, such as at the seafloor110 and at an interface 112 inside the rock formation. Reflected energymay be detected by sensors or receivers 106 (e.g., hydrophones,geophones and/or accelerometers) carried by the streamers. The seismicdata represents the detected energy.

The bird's-eye view in FIG. 2 shows that, upon activating seismic source200, seismic data corresponding to an illumination area 210 having awidth I₁=D is acquired with a streamer spread 220 having a width L₁=2×D.The illumination width is determined by multiple factors, such as themagnitude of emitted energy, energy attenuation along the propagationpath from the source to the receiver via the underground formation,noise level, depth range of interest, receiver's sensitivity, etc. Inthis document, the term “illumination width” refers to a cross-linewidth that can be explored using a reference source.

Illumination area 210 is a locus of mid-points between the sourceactivation location and receivers detecting reflected energy. If areceiver is at a cross-line distance x from the source activationlocation, then the mid-point is at a cross-line position x/2 from thesource activation location. The term “cross-line” indicates a directionperpendicular to the towing direction T and to gravity g (both shown inFIG. 1). The streamer spread is made of plural streamers towedunderwater in such a way as to maintain predetermined cross-linedistances from one another. Six streamers towed at 50 m cross-linedistance between adjacent streamers form a streamer spread with across-line width of 250 m. The streamer spread cross-line distance isthe distance between the leftmost and rightmost streamers. For a spreadconfiguration having M streamers with a distance between two consecutivestreamers of d, the width is (M−1)×d.

In order to acquire high-resolution data with this conventional marineseismic data acquisition system, the distance between adjacent saillines (which are suggested by the arrows pointing in the towingdirection) is S₁=D. Here the sail lines are defined by the streamerspread's trajectory, more specifically by the trajectory of the middleof the streamer spread. The bottom half of FIG. 2 illustrates the dataacquisition system sailing along a sail line adjacent to the sail linealong which the data acquisition represented in the upper half sails.High sail line density takes a long time and is, therefore, expensive.

Thus, there is a need to provide data acquisition systems and methodsthat would acquire high-resolution seismic data faster and at less costthan conventional approaches.

SUMMARY

Methods and systems acquire high-resolution seismic data faster andcheaper than conventional means by using plural sources having a largesource separation, with at least one source towed above the streamerspread.

According to an embodiment, there is a method for seismic dataacquisition that includes simultaneously towing N seismic sources (withN≥2) and a streamer spread. The seismic sources are towed along sourcelines that are at a source cross-line distance D there-between which isat least equal to an illumination width. At least one of the two seismicsources is towed above the seismic spread. The streamer spread, whichhas a spread cross-line width L larger than (N+1) times the sourcecross-line distance, is towed at a position relative to the seismicsources that allows receivers along streamers of the streamer spread todetect underground reflections of seismic waves generated by the seismicsources. The method further includes acquiring seismic datacorresponding to the underground reflections while the streamer spreadis towed along a sail line.

According to another embodiment, there is a marine seismic dataacquisition system including N seismic sources (with N≥2), a streamerspread including plural streamers and towing equipment is configured toenable simultaneously towing the seismic sources and the streamerspread. The seismic sources are towed along source lines that are at asource cross-line distance D there-between, which is at least equal toan illumination width. The streamer spread, which has a cross-line widthlarger than (N+1) times the source cross-line distance, is towed at aposition relative to the seismic sources that allows receivers alongstreamers of the streamer spread to detect underground reflections ofseismic waves generated by the two seismic sources, at least one of theseismic sources being towed above the seismic spread.

According to another embodiment, there is a method for reducing a surveytime for a given area relative to a base survey time achievable bysweeping the given area with a first seismic source and a streamerspread having a width substantially equal to twice a source illuminationwidth. The method includes providing at least one second seismic source,and adding streamers to the streamer spread to extend a spreadcross-line width to at least three times the source illumination width.The method further includes simultaneously towing the first and the atleast one second seismic source along source lines that are at a sourcecross-line distance which is at least equal to the illumination width.The streamer spread is towed at a position relative to the first and theat least one second seismic source that allows receivers along streamersof the streamer spread to detect underground reflections of seismicwaves generated by the first and the at least one second seismic source,at least one of the seismic sources being towed above the seismicspread. The method also includes acquiring seismic data corresponding tothe underground reflections while the streamer spread is towed along asail line.

BRIEF DESCRIPTION OF THE DRAWINGS

The accompanying drawings, which are incorporated in and constitute apart of the specification, illustrate one or more embodiments and,together with the description, explain these embodiments. In thedrawings:

FIG. 1 illustrates a generic marine survey setup;

FIG. 2 is a bird's-eye view of a conventional marine survey system;

FIG. 3 is a bird's-eye view of a marine survey system with two sourceshaving a large cross-line separation between them;

FIG. 4 is a bird's-eye view of a marine survey system according to anembodiment;

FIG. 5 is a bird's-eye view of a marine survey system according toanother embodiment;

FIG. 6 is graphic representation related to a marine survey systemaccording to another embodiment;

FIG. 7 is a bird's-eye view of a marine survey system according toanother embodiment;

FIG. 8 is a bird's-eye view of a marine survey system according toanother embodiment;

FIG. 9 is a bird's-eye view of a marine survey system according to yetanother embodiment;

FIG. 10 is a flowchart of a method for seismic data acquisition,according to an embodiment;

FIG. 11 is a flowchart of a method for reducing a survey time, accordingto an embodiment;

FIG. 12 is an illustration of near-field data acquisition with aconventional data acquisition system; and

FIG. 13 is an illustration of near-field data acquisition with a dataacquisition system according to an embodiment.

DETAILED DESCRIPTION

The following description of the embodiments refers to the accompanyingdrawings. The same reference numbers in different drawings identify thesame or similar elements. The following detailed description does notlimit the invention. Instead, the scope of the invention is defined bythe appended claims. The following embodiments are discussed, forsimplicity, with regard to a marine seismic data acquisition. However,the current inventive concepts may be used for other types of surveys,such as surveys using electromagnetic waves or land surveys.

Reference throughout the specification to “one embodiment” or “anembodiment” means that a particular feature, structure or characteristicdescribed in connection with an embodiment is included in at least oneembodiment of the subject matter disclosed. Thus, the appearance of thephrases “in one embodiment” or “in an embodiment” in various placesthroughout the specification is not necessarily referring to the sameembodiment. Further, the particular features, structures orcharacteristics may be combined in any suitable manner in one or moreembodiments.

According to various embodiments described in this section,high-resolution, efficient data acquisition is achieved using at leasttwo seismic sources at a source cross-line distance at least equal to anillumination width, with at least one of the two sources being towedabove the streamer spread.

FIG. 3 is a bird's-eye view of a data acquisition system in which avessel 300 tows two sources 310 and 320. These sources and sources inthe other embodiments described in this section may be impulsive (e.g.,air-guns) or non-impulsive (e.g., vibrators or detuned air-gun sources)or a combination of different type of sources. The sources follow sourcelines 315 and 325, respectively, at a cross-line distance equal to theillumination width, D, from one another. In FIG. 2, the source line isthe same as the sail line, but in FIG. 3, two source lines correspond toeach sail line. Sources 310 and 320 illuminate an area 322 of widthI₂=2×D if data is acquired using a streamer spread 330 having a spreadcross-line width of at least L₂=3×D. For example, ten streamers towed at50 m cross-line distance between adjacent streamers form a streamerspread with a cross-line width of 450 m. Distance between the sail lines(which are indicated by the up-pointing arrows) may then be doubled,S₂=2×D. In the embodiments described in this section, the receiverscarried by the streamers may be single-sensor or multi-sensors(recording pressure and particle velocity or acceleration).

The bottom half of FIG. 3 illustrates the data acquisition systemsailing along a sail line adjacent to the sail line along which the dataacquisition represented in the upper half sails. On this adjacent sailline, the sources are towed along source lines 335 and 345. Note thatthe cross-line distance between the source lines (i.e., 315 to 325, 325to 335, 335 to 345) is equal to illumination width D.

Based on a similar strategy, N sources simultaneously towed along sourcelines at D cross-line intervals may be used to illuminate an area with across-line width equal to I=N×D using a streamer spread having L=(N+1)×Dspread cross-line width. The distance between adjacent sail lines maythen be S=N×D. Using such a data acquisition system, N source lines areacquired simultaneously for each sail line.

The data acquisition system illustrated in FIG. 3 may be furtherimproved by towing one of the two sources above the streamer spread.FIG. 4 is a bird's-eye view of a marine survey system according to anembodiment. Similar to the marine data acquisition system in FIG. 3,this system includes two sources 410 and 420 towed along source lines415 and 425, respectively, at a cross-line distance equal toillumination width D from one another. However, in this system, thesources are also at an inline distance D′ (the inline direction is thetowing direction), with source 420 towed above the spread 430. Forexample, distance D′ may be about 3 km, the streamers may be towed atdepths between 25 m and 50 m, and seismic source 420 is towed at depthsbetween 5 and 20 m. The streamers may be instrumented with depthcontrolling devices to be towed while maintaining a depth-varyingprofile as described, for example, in U.S. Pat. Nos. 9,134,446,8,531,912, 8,593,904, 8,792,296 and U.S. Patent Application PublicationNo. 2014/0050047.

In this case, sources 410 and 420 illuminate adjacent but inline-shiftedrectangular areas 417 and 427, respectively. The term “inline” relatesto the towing direction. The width of the area illuminated by sources410 and 420 is I₃=2×D. A streamer spread having a cross-line width of atleast L₃=3×D is used to acquire seismic data related to both sources.The distance between adjacent sail lines is S₃=2×D. The bottom half ofFIG. 4 illustrates the data acquisition system sailing along a sail lineadjacent to the sail line along which the data acquisition representedin the upper half sails. As in FIG. 3, the cross-line distance betweenadjacent source lines (i.e., 415 to 425, 425 to 435, 435 to 445) relatedto the same or adjacent sail lines is equal to illumination width D.

The advantage of acquiring data with a source towed above the streameris increased azimuth coverage, since the streamer spread is able torecord reflections coming from all directions for this source. Here, theazimuth is an angle in horizontal plane, between the towing directionand a line from the source-activation location to the receiver location.Thus, for the source towed above the streamer spread, azimuth range is0° to 360°.

In FIG. 4, the sources and the streamer spread are towed by the samesingle vessel. However, practical considerations lead to using themarine data acquisition system in FIG. 5 to acquire seismic data havingthe same quality (density and azimuth coverage) as the FIG. 4 system.The marine data acquisition system in FIG. 5 uses two vessels 500 and501 to tow sources 510 and 520, respectively. Vessel 500 also towsstreamer spread 530, which includes extra streamers 532 to balance thetowed load. The spread cross-line width of streamer spread 530 isL₄=4×D. As in FIGS. 3 and 4, sources 510 and 520 are towed along sourcelines such as 515 and 525 while on a first sail line (as in the upperhalf of FIG. 5), or 535 and 545 (as in the lower half of FIG. 5) whileon an adjacent second sail line. The cross-line distance betweenadjacent source lines remains equal to illumination width D. Thecross-line distance between the adjacent sail lines is S₄=2×D and theillumination width I₄=2×D.

In order to make more homogeneous the fold of the illumination imprintof both sources (aspect that is more extensively discussed later), thespread width could be extended with extra outer streamers. For Nsources, in order to achieve a homogenous-fold illumination width N×D,the streamer spread width is (N+3)×D. For example, for two sources, thestreamer spread may be extended to a width of 5×D. FIG. 6 shows that inaddition to the horizontal illumination 2×D of adjacent illuminationareas 610 and 620 corresponding to sources A and B at a distance Dthere-between, seismic data related to symmetric areas 630 and 640 maybe acquired with the 5×D-wide streamer spread sailing along sail-line600. The lower part of FIG. 6 illustrates similar areas 612-642(corresponding to 610-640) when the data acquisition system including a5×D-wide streamer spread sails along sail-line 602, adjacent to sailline 600. The cross-line distance between the adjacent sail linesremains 2×D. If a 4×D streamer spread is used, then seismic datacorresponding to areas 630 and 632 can be acquired but seismic datacorresponding to areas 640 and 642 cannot be acquired; therefore, theseismic data would not have uniform quality over the surveyed area.

Variations of the data acquisition systems in FIGS. 4 and 5 may haveboth sources towed above the streamer spread. The source lines may alsobe symmetric relative to a line parallel to the towing direction at halfwidth of the streamer spread.

A technique employed to achieve more seismic data diversity enablingsmaller bin sizes is to use dual sources. A dual source includes twoindividual sources separated by a cross-line distance equal to half thedistance between the streamers in the streamer spread. The individualsources are towed symmetrically lateral relative to the source line. Theindividual sources are activated in a flip-flop mode. Using dual sourcesallows more meaningful and smaller cross-line bins than when a singleindividual source is used.

FIGS. 7-9 illustrate embodiments using dual or plural sources towedalong source lines at a source cross-line distance equal to theillumination width, with some sources towed above the streamer spread.The number of streamers and distances there-between specified in thedescriptions are merely illustrations, not intended to be limiting.These source arrangements put the individual sources at differentcross-line distances from the streamers, enabling binning the seismicdata in smaller interleaved bins.

FIG. 7 illustrates a data acquisition system including dual sources 710and 720, with source 720 towed over streamer spread 730. Streamer spread730 includes twelve streamers at 50 m cross-line distance from oneanother. Source line 700 corresponding to source 710 coincides with sailline 705, and is at D=150 m from source line 701 corresponding to source720. The individual sources of dual sources 710 and 720 are shiftedabout 12.5 m cross-line relative to the respective source lines 700 and701.

Source line 700 is substantially in the middle of the streamer spreadand about half cross-line distance between the 6^(th) and 7^(th)streamers (counting from left to right). Source line 701 is about halfcross-line distance between the 9^(th) and 10^(th) streamers. FIG. 7also indicates (using dashed lines) the sail lines 704 and 706 andcorresponding source lines adjacent to sail line 705, along which theillustrated system sails.

FIG. 8 illustrates a data acquisition system including dual sources 810and 820, both sources being towed over streamer spread 830. Streamerspread 830 includes ten streamers at 50 m cross-line distance from oneanother. Source line 800 corresponding to source 810 and source line 801corresponding to source 820 are at D=150 m from one another andsymmetric relative to sail line 805. Source lines 800 and 801 overlapthe 4^(th) and 7^(th) streamers respectively. The individual sources ofdual sources 810 and 820 are shifted about 12.5 m cross-line relative tothe respective source lines 800 and 801. FIG. 8 also indicates (usingdashed lines) sail lines 804 and 806 and the corresponding source linesadjacent to sail line 805 along which the illustrated system sails.

FIG. 9 illustrates a data acquisition system including four sources 910,915, 920 and 925. Sources 910 and 915 are towed ahead of the streamer,while sources 920 and 925 are towed over streamer spread 930. Similar tostreamer spread 830, streamer spread 930 includes ten streamers at 50 mcross-line distance from one another. Individual sources 910 and 920 areat 12.5 m cross-line from source line 900, and individual sources 915and 925 are at 12.5 m cross-line from source line 901. Source line 900is at D=150 m from source line 901, the source lines being symmetricrelative to sail line 905. FIG. 9 also indicates (using dashed lines)sail lines 904 and 906 and the corresponding source lines adjacent tosail line 905 along which the illustrated system sails.

Sources 910, 915, 920 and 925 may be of different types. In oneembodiment, sources 910 and 915 are air gun-type, while sources 920 and925 are vibrator-type. The sources may emit different excitations withdifferent frequencies (bandwidth or sweeps) or may be towed at differentdepths.

FIG. 10 is a flowchart of a method 1000 for seismic data acquisition,according to an embodiment. Method 1000 includes simultaneously towingtwo seismic sources along source lines at a source cross-line distance Dat least equal to an illumination width, and a streamer spread at 1010.More than two (i.e., N>2) seismic sources may be used. The streamerspread has a spread cross-line width larger than three times the sourcecross-line distance, and is towed at a position relative to the twoseismic sources that allows receivers along streamers of the streamerspread to detect underground reflections of seismic waves generated bythe two seismic sources. If N>2 sources having cross-line distancesthere-between at least equal to an illumination width are used then thestreamer spread has a width at least equal to (N+1)×D. At least one ofthe seismic sources is towed above the spread. The source may be towedabove the spread by a vessel other than the vessel towing the streamerspread. The source(s) may be towed about a middle of an inline length ofthe streamers, the inline length extending along the towing direction.

Method 1000 further includes acquiring seismic data corresponding to theunderground reflections while the streamer spread is towed along a sailline, at 1020. Thus, seismic data corresponding to two (or more) sourcelines is acquired simultaneously, decreasing the survey time.

At least one of the two seismic sources may be a dual source activatedin a flip-flop mode. In one embodiment, both seismic sources are dualsources activated in a flip-flop mode, with an individual source fromone dual source activated simultaneously with an individual source ofthe other dual source. The source lines may be substantially symmetricrelative to the sail line.

The streamers may have a depth-varying profile while towed. Thestreamers may be towed at depths between 25 m and 50 m, and the twoseismic sources may be towed at depths between 5 m and 20 m. Beyondspecific ranges, the streamers are towed such as to allow towing asource over them. The sources may be multi-level (i.e., having sourceelements at different depths, e.g., at 6, 10 and 15 m).

The source cross-line distance, a cross-line distance between adjacentsail lines and the spread cross-line width, may be selected so as tominimize fold variation in the seismic data.

In view of the above-described data-acquisition-related techniques,there is a method for reducing a survey time for a given area relativeto a base survey time achievable by sweeping the given area with a firstseismic source and a streamer spread having a width substantially equalto twice a source illumination width. FIG. 11 is a flowchartillustrating steps of such a method. Method 1100 includes providing asecond seismic source, at 1110, and adding streamers to the streamerspread to extend a spread cross-line width to at least three times thesource illumination width, at 1120.

Method 1100 further includes, at 1130, simultaneously towing the firstand second seismic sources along source lines, and the streamer spreadat a position relative to the first and second seismic source, whichallows receivers along streamers of the streamer spread to detectunderground reflections of seismic waves generated by the first and thesecond seismic sources, with at least one of the first and secondseismic source towed above the seismic spread. A source cross-linedistance between the source lines is at least equal to the illuminationwidth. In a broader view more sources may be added and the streamerspread width is then adequately extended. For example, if N>2 seismicsources are towed simultaneously at distances there-between at leastequal to the illumination width D, the streamer spread width is at least(N+1)×D.

Method 1100 then includes acquiring seismic data corresponding to theunderground reflections while the streamer spread is towed along a sailline, at 1140.

Towing the sources over the spread has the advantage that the cross-linedistribution of near-offsets data is substantively enhanced, making itpossible to acquire data even for zero-offset. To illustrate thisfeature consider a comparison between FIGS. 12 and 13. FIG. 12illustrates a conventional marine data acquisition system having source1210 towed ahead of streamer spread 1220. Circle 1230 emphasizes thelocation of receivers recording near-offset data (i.e., the thickerlines within this circle) when the conventional marine data acquisitionsystem is towed along sail line 1201. At the bottom of FIG. 12, data incircle 1230 is reproduced with a center B for the source position on thecorresponding source line (here the same as the sail line), next tocorresponding data (in circles centered on A and C for the sourcepositions along source lines respectively) acquired when thisconventional marine data acquisition system is towed along adjacent saillines 1200 and 1202.

FIG. 13 illustrates a marine data acquisition system having two sources1310 and 1315 towed above of streamer spread 1320. The cross-linedistance between the sources is substantially equal to the sources'illumination width. Overlapping circles 1330 and 1335 emphasize thelocation of receivers recording near-offset data (again, the thickerlines within the circles) acquired when the marine data acquisitionsystem is towed along sail line 1301. Note that data corresponding totwo sail lines is acquired when this marine data acquisition systemsails along one sail line.

At the bottom of FIG. 13, circles 1330 and 1335 are reproduced with thesources in the center on the corresponding source lines SL3 and SL4,next to corresponding circles with the sources along source lines SL1,SL2, SL5 and SL6 showing the receivers acquiring near-offset data whenthis marine data acquisition system towed along adjacent sail lines 1300and 1302. A visual comparison of the bottom portions of FIGS. 12 and 13reveals the substantive quantity and quality improvement of thenear-offset data when sources are towed above the streamer spread.

Although the features and elements of the present embodiments aredescribed in the embodiments in particular combinations, each feature orelement can be used alone without the other features and elements of theembodiments or in various combinations with or without other featuresand elements disclosed herein. The methods or flowcharts provided in thepresent application may be implemented in a computer program, softwareor firmware tangibly embodied in a computer-readable storage medium forexecution by a general-purpose computer or a processor.

This written description uses examples of the subject matter disclosedto enable any person skilled in the art to practice the same, includingmaking and using any devices or systems and performing any incorporatedmethods. The patentable scope of the subject matter is defined by theclaims, and may include other examples that occur to those skilled inthe art. Such other examples are intended to be within the scope of theclaims.

What is claimed is:
 1. A method for seismic data acquisition, the methodcomprising: simultaneously towing N seismic sources so that any twoadjacent seismic sources of the N seismic sources are separated by asource cross-line distance D, with N≥2, wherein the source cross-linedistance D is perpendicular to a sail line, and a streamer spread havinga spread cross-line width L, larger than the source cross-line distanceD, and the streamer spread is towed with a first vessel so that a firstseismic source of the N seismic sources is located above the seismicspread and a second seismic source of the N seismic sources is locatedahead of the seismic spread, along the sail line; activating at leastone of the N seismic sources; and acquiring, with the streamer spread,seismic data corresponding to underground reflections while the streamerspread is towed along the sail line, wherein the first seismic source,which is adjacent to the second seismic source along the cross-linedistance, is maintained at a non-zero distance D′ behind the secondsource, along the sail line, and the first seismic source and the secondseismic source are towed within an area swept by the streamer spread. 2.The method of claim 1, wherein the first seismic source of the N seismicsources is towed about a middle of an inline length of the streamers. 3.The method of claim 1, wherein at least one of the N seismic sources isa dual source activated in a flip-flop mode.
 4. The method of claim 1,wherein the N seismic sources are dual sources activated in a flip-flopmode, one individual source from each of the N seismic sources beingactivated simultaneously.
 5. The method of claim 1, wherein, in ahorizontal plane, source lines followed by the N seismic sources aresubstantially symmetric relative to the sail line.
 6. The method ofclaim 1, wherein the cross-line width L is larger than (N+1) times thesource cross-line distance D.
 7. The method of claim 1, wherein thesecond seismic source is towed with the second vessel.
 8. The method ofclaim 1, wherein at least one of the N seismic sources is a multi-levelseismic source.
 9. The method of claim 1, wherein the first seismicsource is towed with a second vessel.
 10. The method of claim 1, whereinthe second seismic source is towed about a middle of the streamer spreadcross-line width L.
 11. A marine seismic data acquisition systemcomprising: N seismic sources, where N≥2; a streamer spread includingplural streamers; and a towing equipment configured to enablesimultaneously towing of the N seismic sources so that two adjacentseismic sources of the N seismic sources are separated by a sourcecross-line distance D, wherein the source cross-line distance D isperpendicular to a sail line, and the streamer spread having across-line width L, larger than the source cross-line distance D, andthe streamer spread is towed with a first vessel so that a first seismicsource of the N seismic sources is being towed above the seismic spread,and a second source of the N seismic sources is located ahead of theseismic spread, along the sail line, wherein the first seismic source,which is adjacent to the second seismic source along the cross-linedistance, is maintained at a non-zero distance D′ behind the secondsource, along the sail line, and the first seismic source and the secondseismic source are towed within an area swept by the streamer spread.12. The marine seismic data acquisition system of claim 11, wherein thetowing equipment enables towing the first seismic source over thestreamer spread about a middle of an inline length of the streamerspread, the inline length extending along the sail line.
 13. The marineseismic data acquisition system of claim 11, wherein the towingequipment enables towing the second seismic source over the streamerspread about a middle of the cross-line width L of the streamer spread.14. The marine seismic data acquisition system of claim 11, wherein theN seismic sources are dual sources activated in a flip-flop mode, andindividual sources of the N seismic sources are being activatedsimultaneously.
 15. The marine seismic data acquisition system of claim11, wherein, the towing equipment is configured to enable source linesfollowed by the N seismic sources to be substantially symmetric relativeto the sail line, in a horizontal plane.
 16. The marine seismic dataacquisition system of claim 11, wherein the towing equipment enables thestreamer spread to have the cross-line width L larger than (N+1) timesthe source cross-line distance D.
 17. The marine seismic dataacquisition system of claim 11, wherein the first seismic source istowed with a second vessel.
 18. The marine seismic data acquisitionsystem of claim 11, wherein at least one of the seismic sources is amulti-level seismic source.
 19. The marine seismic data acquisitionsystem of claim 11, wherein the first vessel also tows the secondseismic source.
 20. A method for seismic data acquisition, the methodcomprising: towing N seismic sources so that two adjacent seismicsources of the N seismic sources are separated by a source cross-linedistance D, with wherein the source cross-line distance D isperpendicular to a sail line; towing a streamer spread having a spreadcross-line width L, which is larger than the source cross-line distanceD, and the streamer spread is towed so that a first seismic source ofthe N seismic sources is located above the seismic spread and a secondseismic source of the N seismic sources is located ahead of the seismicspread, along the sail line; activating at least one of the N seismicsources; and acquiring, with the streamer spread, seismic data while thestreamer spread is towed along the sail line.